Retrievable well packers



Aug. 27, 1968 "r. L. ELLISTON 3,398,795

RETRIEVABLE WELL PACKERS Filed Aug. 16, 1965 7 Sheets-Sheet l INVENTOR Thomas L. Ellisfon 7, 1968 T. L. ELLISTON 3,398,795

. RETRIEVABLE WELL PACKERS Filed Aug. 16, 1965 7 Sheets-Sheet 2 mo )1 4s Y 4 M ii i IO 3 w 47 I I29 m 13f .1:

INVENTOR 5 J Thomas L. Elliston My Fig.2 W%m;

Aug. 27, 1968 T. L. ELLISTON 3,398,795

RETRIEVABLE WELL PACKERS Filed Aug. 16, 1965 7 Sheets-Sheet 5 INVENTOR FIG. I9 FIG l8 THOMAS 1.. ELLISTON BY ,/w W

ATTORN EYS Aug. 7, 1968 T. L. ELLISTON 3,398,795

RETRIEVABLE WELL PACKERS Filed Aug. 16, 1965 7 Sheets-Sheet 4 FlGr I5 FIG.-I7

INVENTOR THOMAS L. ELLISTON FIG-l4 BY W X6 2 ATTORNEYS Aug. 27, 1968 Filed Aug. 16, 1965 T. L. ELLISTON 3,398,795

RETRIEVABLE WELL PACKERS '7 Sheets-Sheet 5 FIG.2OB

INVENTOR '[HOMAS L. ELLISTON BY w a ATTORNEYS Aug. 27, 1968 T. ELLISTON 3,398,795

RETRIEVABLE WELL PACKERS Filed Aug. 16, 1965 7 Sheets-Sheet 6 JE-sos FIG. 2| B INVENTOR THOMAS L. ELLISTON F l G :2 1A

United Smtes Patent 3,398,795 Patented Aug. 27, 1968 3,398,795 RETRIEVABLE WELL PACKERS Thomas L. Elliston, Dallas, Tex., assignor to Otis Engineering Corporation, Dallas, Tex., a corporation of Delaware Filed Aug. 16, 1965, Ser. No. 479,966 26 Claims. (Cl. 166-120) ABSTRACT OF THE DISCLOSURE A well packer having anchoring means disposed on opposite sides of a sealing means for holding the sealing means against displacement in either longitudinal direction, and designed for use with a connector and sealing assembly which locks the anchoring means against displacement; said packer being removable from anchoring position in a well bore by upward longitudinal force applied to the mandrel of the packer after the connector and sealing means has been removed therefrom.

This invention relates to well apparatus and tools and more particularly to well tools which are positionable in a fiow conductor to control fluid flow therethrough and to well apparatus utilizing such well tools and providing an inner flow passage through such flow conductor.

An object of the invention is to provide a new and improved well tool having an elongate body or mandrel which is positionable in a flow conductor and is provided with anchoring means engageable with the internal surfaces of the flow conductor for anchoring the mandrel against movement therein.

Still another object is to provide a well tool having a mandrel provided with upper and lower anchoring means and a sealing means wherein the anchoring and sealing means are moved to their anchoring and sealing positions upon upward movement of the mandrel relative thereto and wherein the anchoring and sealing means are released for movement to their retracted positions upon further upward movement of the mandrel relative thereto.

Still another object is to provide a well tool wherein the mandrel and the lower anchoring means are provided with coengageable means for releasably holding the mandrel against upward movement relative to the lower anchoring means.

A further object is to provide a well tool wherein the mandrel is tubular and is locked against movement relative to the lower anchoring means by a member of a running or connector tool which extends through the mandrel.

Still a further object is to provide a well tool wherein such running connector tool member is tubular and is longitudinally slidably movable therein to permit longitudinal movement relative to the packer of a flow conductor to which such running or connector tool is connected.

Another object is to provide a well apparatus of the type described wherein the tool on the lower end of the string of tubing includes a seal mandrel releasably positionable in the mandrel of the well packer for sealing between the packer mandrel and the extension.

Still another object is to provide a well apparatus wherein the extension is releasable from the seal mandrel after the seal mandrel is secured to the packer mandrel for movement to a position wherein it is free to slide longitudinally through the seal mandrel.

Another important object of the invention is to provide a well packer having a mandrel on which are mounted upper and lower anchoring means, each of the anchoring means including a slip carrier, slips carried by the carrier and an expander for expanding the slips radially outwardly upon longitudinal movement of the slips relative to the expander means which may include a lower slip carrier, slips carried thereby and a sealing mounted on the mandrel between the expanders of the two anchoring means wherein the mandrel and the slip carriers are releasably secured to one another, the slip carrier of the upper anchoring means being movable downwardly relative to the upper expander to move its slips into expanded positions.

Still another object is to provide a well packer of the type described wherein the seal means and the lower slips are moved to expanded, sealing and anchoring positions upon an upward movement being imparted to the mandrel after the upper slips are in expanded positions.

Still another object is to provide a well packer of the type described wherein the slip carrier of the lower anchoring means and the mandrel have coengageable latch means for latching the mandrel against longitudinal movement relative to the slip carrier, wherein the latch means are held locked in latching position by a member of a running or connector tool which extends through the mandrel.

A further object is to provide a well packer of the type described wherein the mandrel has means for releasing the slips of the upper anchoring means for movement to their inner retracted positions and subsequently moving the slips of the lower anchoring means therewith upon further upward movement of the mandrel relative to the lower slip carrier to render the anchoring means inoperative.

A still further object is to provide a well packer of the type described wherein the mandrel of the well packer has internal latch means engageable by running or con nector tool by means of which the mandrel may be moved.

A still further object is to provide a well packer wherein a seal mandrel of a connector tool is releasably positionable in the packer mandrel to seal between the extension of the connector tool and the mandrel and which permits longitudinal movement of such tubular extension relative to the seal and packer mandrel.

Still another object is to provide a well tool of the bridge plug type wherein the mandrel is closed by a plug means and which is provided with a valve member mounted in the mandrel for limited longitudinal movement therein which must be moved to an upper open position, before an upward force can be exerted on the mandrel to open a bypass port to equalize pressure across the mandrel before its anchoring and seal means can be free for movement to their retracted positions.

The invention is therefore directed to a well tool having an elongate tubular mandrel with longitudinally spaced anchoring means thereon, with an expansible sealing means therebetween, the anchoring means and sealing means being moved to anchoring and sealing positions by relative longitudinal movement of the anchoring means toward each other causing anchoring engagement of the anchoring means and deformation of the sealing means to sealing position, and a central member disposed in the mandrel holds the mandrel against longitudinal movement relative to the anchoring means and sealing means whereby the well tool is maintained anchored in sealing position. A connector and seal member provides flow directing communication with mandrel and Well tubing, and a sliding seal is provided permitting expansion and contraction of the tubing without disturbing the anchored sealing position of the well tool. The well tool is removable from anchored sealing position by continuous longitudinal movement of the mandrel relative to the anchoring means and sealing means after the central member has been moved from holding position.

Additional objects and advantages of the invention will be readily apparent from the reading of the following description of a device constructed in accordance with the invention, and reference to the accompanying drawings thereof, wherein:

FIGURE 1 is a vertical sectional view of the upper portions of a well packer embodying the invention and showing a running tool connected thereto;

FIGURE 1A is a vertical sectional view similar to FIGURE 1 being a continuation thereof and showing the lower portions of the well packer and the running tool;

FIGURE 2 is a vertical, sectional 'view showing the upper portions of the well packer illustrated in FIG- URES 1 and 1A and the running tool connected thereto in the positions assumed thereby when the packer is in anchored sealing position in a well casing;

FIGURE 2A is a view similar to FIGURE 2 being a continuation thereof and showing the lower portions of the well packer and running tool;

FIGURES 3 and 4 are sectional views taken on lines 33 and 4 4, respectively of FIGURE 1;

FIGURES 5, 6, 7 and 8 are sectional views taken on line 55, 66, 7-7, and 88, respectively, of FIG- URE 1A;

FIGURES 9 andlO are cross sectional views taken on lines 9-9 and 1010, respectively, of FIGURE 2A;

FIGURE 11 is a side view of the upper expander of the Well packer;

FIGURE 12 is a fragmentary view of the lower end portion of the packer mandrel;

FIGURE 13 is a vertical, partly sectional view showing a J-slot of the running tool illustrated in FIGURES l and 1A;

FIGURE 14 is a vertical, partly sectional view of a connector tool useable with the well packer;

FIGURE 15 is a fragmentary, vertical partly sectional view showing a J-slot of the connector tool;

FIGURE 16 is a sectional view taken on line 1616 of FIGURE 15;

FIGURE 17 is a vertical, partly sectional view with some parts broken away of another connector tool showing it in position in the mandrel of the well packer;

FIGURE 18 is a vertical view showing the extension of the connector tool illustrated in FIGURE 17 extending through the well packer which is anchored and set in position in a well casing;

FIGURE 19 is a view taken on line 19-19 of FIG- URE 17;

FIGURE 20A is a vertical, partly sectional view of the upper portion of a modified form of the well packer;

FIGURE 20B is a view similar to FIGURE 20A, being a continuation thereof and showing the lower portion of the well packer;

FIGURE 21A is a vertical, partly sectional view showing the upper portion of another modified form of the well packer and portions of the running and setting tool by which it is lowered into a well casing and set therein;

FIGURE 21B is a view similar to FIGURE 21A, being a continuation thereof;

FIGURE 22A is a vertical, partly sectional view of a bridge plug embodying the invention and of the lower portions of a running and setting tool secured thereto;

FIGURE 22B is a view similar to FIGURE 22A, being a continuation thereof; and

FIGURE 23 is a sectional view taken on line 2323 of FIGURE 10.

Referring now particularly to FIGURES 1 through 13 of the drawing, the well tool or packer 35 embodying the invention includes a tubular mandrel 36 having a top or head section 37 and an elongate main section 38 whose top end portion is threaded into the lower end portion of the head section, as at 39. The main mandrel section has mounted thereon an upper slip carrier 42, a plurality of upper slips 43 mounted on the upper slip carrier for radial movement between inner retracted and outer expanded portions, an upper expander assembly 44 for expanding the upper slips 43, a packing or seal element 45, a lower slip expander 46, a plurality of lower slips 47 and a lower slip carrier 48.

The lower externally threaded end portion 54 of the top mandrel section is receivable in the similar internally threaded tubular connector 55 whose lower portion is telescoped over the reduced top end 56 of the upper slip carrier and is secured thereto by means of screws 57 which extend through suitable apertures of the connector into outwardly opening threaded bores of the slip carrier. The upper slip carrier, 44 has an internal inwardly and downwardly extending cam surface 58 which is engageable with the similarly inclined outer surfaces 59 of a plurality of wedge ring segments 60 which are provided with internal upwardly facing teeth. The wedged shaped ring sections are biased downwardly to cause their internal teeth to engage the external surface of the main mandrel section to prevent downard movement of the main mandrel section relative to the upper slip carrier by a spring 61 disposed about the main mandrel section and within the upper slip carrier. The lower end portion of the spring engages the upper surfaces of the wedge ring segments and its upper end portion engages the bottom surface of a split retainer ring 62 whose outer portions are received in an internal annular recess of the upper slip carrier.

The upper substantially T-shaped handle portions of the upper slips 43 extend upwardly into the enlarged lower end portion 71 of the bore of the slip carrier and are held relea-sably against outward movement by a plurality of circumferentially spaced bow springs 74 whose upper end portions are receivable in the external longitudinal recesses 75 of the slip carrier and are rigidly secured thereto by means of screws 76. The lower portions of the longitudinal recesses 75 open inwardly into the lower enlarged bore portion 71 of the slip carrier. The lower end portions of the bow springs extend inwardly into the bore of the slip carrier and engage the outer surfaces 78 of the slips to resiliently hold them in their retracted positions. The intermediate or middle portions of the bow or drag springs 74 extend radially outwardly of the packer to engage the internal surfaces of a well casing for a purpose to be described below.

The slip carrier adjacent its lower end is provided with an internal annular flange which provides an upwardly facing shoulder 80 which is engageable with the lower shoulders 81 of the circumferentially outwardly extending sections 82 of the slips to prevent accidental downward disengagement of the slips from the slip carrier. Upward movement of the slips relative to the slip carrier is limited by the engagement of the top surfaces of the slips with the downwardly facing annular shoulder 84 of the slip carrier. The slips at their lower end portions have internal downwardly and outwardly inclined cam surfaces 86 and with external upwardly facing teeth or serrations 87. The slips at their upper ends are provided with internal flanges 88 which provide downwardly facing shoulders 89 for a purpose to be described below.

The expander assembly 44 includes an expander 90 having a plurality of circumferentia'lly spaced upwardly extending resilient fingers 91 which are provided with external bosses 92. The bosses have downwardly facing shoulders 93 and upwardly and inwardly inclined top cam shoulders 94 which are engageable with the internal cam surfaces 86 of the upper slips, The lower end portion of the expander below the shoulders 93 of the bosses 91 is receivable in the upwardly opening annular recess 96 of the tubular expander carrier 97 of the expander assembly. The expander carrier has an internal annular recess 98 in which are receivable the external catch bosses 99 of the fingers. The catch bosses have upwardly and outwardly extending lower cam shoulders which cam the fingers inwardly as the lower portion of the expander is telescoped inwardly into the expander holder and whose upwardly facing shoulders engage the downwardly facing shoulder defining the upper end of the recess 98 to prevent upward movement of the expander from the tubular holder.

The expander holder is held against upward movement on the main mandrel section by a split stop ring 101 whose inner portions are received in an external annular recess of the main mandrel section and whose bottom end shoulder engages the upwardly facing internal annular shoulder 102 provided by an internal flange 103 of the expander holder. The expander holder is releasably secured against downward movement relative to the main mandrel section by one or more shear pins 104 which extend through suitable apertures in the expander holder into suitable lateral ports or bores of the stop ring 101.

The upper ends of the fingers of the expander are held in their expanded position by a wedge ring 106 whose outer surface 107 extends upwardly and outwardly and engages the similarly upwardly and outwardly extending inner cam surfaces 108 of the collet fingers. The wedge ring is releasably secured to the fingers by shear pins 110 which extend through suitable apertures in the collet fingers into radial apertures of the wedge ring.

The tubular resilient packing element 45, made of a suitable plastic, rubber or the like is disposed between upper and lower back-up rings 112 and 113 made of a relatively soft metal such as lead. The upper back-up ring 113 is disposed between the annular bottom end surface of the expander holder 97 and the top end surface of the packing element and the lower back-up ring is disposed between the lower end of the packing element and the annular top end surface of the lower slip expander 46. The lower slip expander is releasably secured to the main mandrel section by one or more shear pins 115 which extend through suitable lateral apertures of the lower expander into suitable lateral ports or bores of the main mandrel section 38. The lower expander is provided at its lower end with an annular downwardly facing stop shoulder 118 for a reason to be described.

The lower slip expander has upwardly and outwardly extending planar cam surfaces 120 engageable with the inner planar surfaces 121 of the lower slips 47 and with dovetail grooves 123 in which is slidably received the similarly sloped tongues 124 of the slips. The tongue and groove connection of the slips with the lower expander prevents outward movement of the slips except upon upward movement of the slips relative to the expander.

The lower slips have downwardly facing serrations or teeth 127 and T-shaped handles 128 at their lower ends which are received in slots 129 of the lower slip carrier 48 of similar configuration. The T-handle prevents circu-mferential displacement of the lower ends of the slips while permitting their radial outward movement. The bottom ends of the T-shaped slots are defined by downwardly and outwardly extending shoulders 130 of the lower slip carrier which are engageable with the lower bottom end surfaces 131 of the slip carrier handles whereby upon upward movement of the slip carrier relative to the slips, the lower slips are cammed outwardly due to the camming engagement of these cam surfaces.

Upward movement of the lower slip expander 46 relative to the lower slip carrier is limited by one or more bolts 132 whose lower ends are threaded in suitable upwardly opening bores of the lower slip carrier and are secured in desired adjust-ed position thereon by nuts 132a threaded on the bolts. Lock washers 132b may be interposed between the nuts and the lower slip carrier. The enlarged heads 132d of the bolts are slidably disposed in longitudinal bores 133 of the lower slip expander. The engagement of the head with the annular upwardly facing shoulder 13312 of the lower slip expander limits upward movement of the expander relative to the bolts and therefore to the lower slip carrier. The lower slip carrier is releasably held in its lower'initial position, FIGURES 1A and 23, relative to the lower expander by shear pins 134 which extend through the bores 133 and engage the top surfaces of the bolts.

The lower slip carrier 48 includes a lower tubular latch section 135 whose upper end is received in a downwardly opening annular recess 137 of the slip carrier and rigidly secured thereto in any suitable manner as by weld 136. The lower slip carrier is held against upward movement on the main mandrel section by a split stop ring 138 whose inner portions are received in an external annular recess of the main mandrel section and whose bottom end shoulder engages an upwardly facing annular stop shoulder 140 of the latch section provided by a reduction of the internal bore of the latch section. An internal annular flange 143 adjacent the bottom end of the latch section is provided with an internal annular recess 144.

The lower end portion of the main mandrel section is provided with a plurality of downwardly opening circumferentially spaced slots -146 which define a plurality of circumferentially spaced resilient collet fingers 149. The collect fingers at their lower ends are provided with internal and external bosses 150 and 151, respectively. The external bosses 151, which are receivable in the internal recess 144 of the latch section 135 have upper and lower shoulders which extend convergently outwardly, the upper shoulders being engageable with a downwardly facing shoulder of the latch section of the slip carrier defining the upper end of the internal recess 144 to hold the main mandrel section of the packer mandrel against upward movement relative to the lower slip carrier when the collect fingers are in their normal positions illustrated in FIGURES 1A and 2A.

The top or latch section 37 of the packer mandrel 36 is provided with a pair of diametrically opposed inwardly extending lugs 154 by means of which the packer is releasably seourable to a running and setting tool which is connectable to the lower end of a flow conductor or string of tubing 161. The running and setting tool includes a tubular connector section 164 into which the lower reduced end 165 of the lower end of the string of tubing is threaded, a tubular latch section 166 whose upper end portions is threaded in the lower end portion of the connector section and dependent tubular extension 167 whose upper end portion is threaded in the lower end portion of the latch section. The extension 167 is adapted to extend through the main mandrel section 38 of the packer to hold the fingers in their normal positions, wherein their external bosses 151 are in the recess 144 of the latch section 135 of the lower slip carrier, by the engagement of its external surface with the inner surfaces of the inner bosses 150 of the fingers 147 of the main mandrel section.

The latch section 166 of the running and setting tool has an external annular flange 170 at its lower end which provides an upwardly facing shoulder 171 which limits downward movement of a suitable seal assembly 172 disposed about the latch section. The seal assembly seals with the internal seal surface 174 of the top mandrel section above the lugs 54. Upward movement of the seal assembly on the latch section of the running and setting tool is limited by the downwardly facing end shoulder 175 of the connector section 164. The latch section 166 has an annular downwardly facing stop shoulder 176 which is engagearble with the stop shoulder 177 of the top packer mandrel section.

The flange 170 has a .pair of diametrically opposed J-slots 180 whose vertical portions 181 open downwardly through the flange and whose upper horizontal portions 182 extend circumferentially from the upper ends of the vertical portions in a clockwise manner as seen in FIGURE 3. The packer is releasably secured to the running tool by telescoping the running tool downwardly into the packer mandrel until the annular shoulder 176 of the running tool engages the shoulder 177 of the packer mandrel and thus stops the downward movement of the running tool. The vertical portions 181 of the J-slots of the running tool are received by the internal lugs 154 of the top packer mandrel section. The ring tool is then rotated in a counter-clockwise direction as seen in FIGURE 3 to move the horizontal portions 182 of the J-slots over the lugs 154 so that when the running and setting tool is lifted upwardly, the upwardly facing shoulders 184 of the latch section of the running tool defining the lower ends of the horizontal portions 182 of the J-slots engage the bottom surfaces 185 of the packer mandrel lugs whereupon the packer is supported by the running tool.

The packer is then lowered by means of the running tool, and the string of tubing 161 to which the running tool is connected, into the upper end of the well causing C with the upper and lower slips and the packing element in their retracted positions. As the bow springs 74 move into the casing their intermediate portions are flexed resiliently inwardly and thereafter frictionally engage the internal surfaces of the well casing as the packer is lowered therethrough. When the packer is at the location in the casing where it is desired that it be set and anchored, the tubing string 161 is rotated in the counter-clockwise direction, as seen from above, and the engagement of the vertical shoulders 186 of the running tool latch section defining the ends of the horizontal portions 182 of the J-slots with the side surfaces 187 of the lugs 154 of the top packer mandrel section causes the packer mandrel to rotate relative to the upper slip carrier 42. Rotation of the upper slip carrier is resisted by the bow springs 74 which engage the internal surfaces of the well casing. The threaded end portion of the top mandrel section is disengaged from the tubular connector 55 of the upper slip carrier 42 such rotation. Once the top mandrel section is disconnected from the upper slip carrier, an upward movement is imparted to the tubing string and therefore to the running tool 160, whereupon the shoulders 184 of the running tool engage the bottom surfaces 185 of the lugs 154 and impart an upward movement to the packer mandrel 36. The bow springs 74 resist upward movement of the slip carrier and the packer mandrel moves upwardly relative to the upper slip carrier, the wedge ring segments 60 permitting such upward movement of the packer mandrel section 38 relative to the upper slip carrier since their internal teeth face upwardly. The cam surfaces 59 and 58 of the wedge ring segments and of the upper slip carrier extend upwardly and outwardly so that any upward movement imparted to the wedge ring segments tends to move them upwardly against the force exerted by the spring 61 and out of binding engagement with the external surface of the main latch mandrel section 38. Upward movement of the packer mandrel also causes upward movement of the upper expander assembly 44, the packing element 34, the lower slips 47 and the lower slip carrier 48.

As the packer mandrel is thus moved upwardly relative to the upper slip carrier and the upper slips, the upper cam or expander surfaces 94 of the bosses 92 of the upper slip expander 90 move into engagement with the cam surfaces 86 of the upper slips and move the slips outwardly and into gripping and anchoring engagement with the well casing. When the slips are in fully expanded position and cannot move further outwardly, upward movement of the upper expander assembly 44 is arrested and continued upward movement of the packer mandrel now causes the shear pins 104 to shear and the packing element 45 to be compressed longitudinally and expanded into sealing engagement with the well casing. When the packing element has been fully compressed and moved into sealing engagement with the well casing, the shear pins 115, which are of greater shear strength than the pins 104, are sheared. Continued upward movement of the packer mandrel causes the pins 134 to shear and the lower slip carrier and the lower slips 47 to be moved upwardly relative to the expander 47 and radially outwardly and into gripping and anchoring engagement with the well casing. The upper slips then hold the upper expander assembly 44 against upward movement in the well casing and the lower slips hold the lower slip expander 46 against downward movement in the well casing. The packer mandrel is now held against downward movement relative to the upper slip carrier by the action of the wedge ring segments 60 so that the packer is now in the anchored and sealing position in the well casing illustrated in FIGURES 2 and 2A. The packer mandrel cannot now be released for upward movement since the tubular extension 167 of the running tool prevents inward movement of the lower ends of the packer mandrel fingers 149. The packer is thus locked in anchored and sealing position in the well casing.

Well fluids from below the Well packer may now circulate to the surface through the running tool and the string of tubing or fluids may be circulated downwardly therethrough. During such fluid circulation, the string of tubing is preferably held in tension in order to prevent any accidental rotation of the tubing string and the running tool which might cause disengagement of the lugs 154 from the J-slots of the running tool.

If it is thereafter desired to remove the well packer from the well, the string of tubing and the running tool secured thereto is rotated in a clockwise manner, as seen from above, to position the downwardly opening vertical portions 181 of the J-slots in alignment with the lugs 154 of the packer mandrel and the string of tubing and the running tool may then be removed to the surface leaving the packer in place in the casing. The tubular extension 167 of the running tool is then disconnected from the latch section 166 and the string of tubing with only the connector section .164 and the latch section 166 of the running tool still connected thereto is again lowered into the well until the running tool again telescopes into the upper end of the packer mandrel with the leg portions 181 of the J-slots receiving the internal lugs 154 of the packer mandrel. Counterclockwise rotation is then again imparted to the string of tubing to move the horizontal portions 182 of the Lslots into alignment with the lugs 154, the string of tubing is then lifted and the shoulders 184 .of the running tool again engage the bottom shoulders 185 of the lugs 154 of the packer mandrel. The packer mandrel is now moved upwardly with the running tool relative to the lower slip carrier since the external bosses 151 of its fingers 149 are now free to move inwardly, the camming engagement of the upper shoulders of the external bosses with an annular upper shoulder defining the upper end of the annular recess 144 of the latch section 135 of the lower slip carrier cams the lower ends of the fingers inwardly.

Upward movement of the packer mandrel now causes the top shoulder of the stop ring 101 to engage the bottom annular shoulder of the wedge ring 106 and, as the upward movement of the packer mandrel is continued, the shear pins 110 are sheared and the wedge ring 106 is moved upwardly from between and out of engagement with the internal cam surfaces 108 of the expander fingers 91 thus freeing the upper ends of the fingers for inward movement. The fingers, which inherently tend to move inwardly from the outer positions in which they are held by the latch ring, move inwardly. As the upward movement of the packer mandrel is continued, the wedge ring moves upwardly relative to the upper slips and when it moves past an intermediate point thereof, the bow springs 74 tend to pivot the lower ends of the slips inwardly out of anchoring engagement with the well casing. As the upward movement of the packer mandrel is continued, the top shoulder of the wedge ring moves into engagement with the downwardly facing shoulders 89 provided by the inner flanges 88 of the slips and the upper slips and their carrier 42 are now moved upwardly with the packer mandrel. When the slips 43 move out of anchoring relation with the well casing and upwardly relative to the expander fingers, the expander assembly 44 is freed to move upwardly relative to the mandrel and is so moved by the resilient packing element 45 which now tends to move back to its original retracted position. As the upward movement of the packer mandrel is continued, the top shoulder of the lower stop ring 138 moves into engagement with the downwardly facing annular shoulder 118 at the lower end of the lower slip expander 46 and moves it upwardly therewith relative to the lower slips. Such upward movement of the lower slip expander with the mandrel now causes the lower slips to be moved inwardly to their retracted positions due to the tongue and groove connection of the slips with the lower slip expander. Once the lower slips are in their retracted positions and cannot move further inwardly due to the engagement of their inner surfaces with the main packer mandrel section 38, the lower slip carrier 48 moves upwardly with the slips due to the engagement of their lower T-shaped handle portions with the lower slip carrier. The packer is then free to move upwardly through the well casing and is removed from the well by lifting the string of tubing and the running tool to the surface.

If the string of tubing is to be subjected to extreme changes in temperature which cause the length of the tubing to vary appreciably due to expansion and contraction, as, for example, in wells where steam injection operations are to be performed, it is preferable that the string of tubing be so connected to the packer as to permit longitudinal movement of the string of tubing relative to the packer which of course is held against movement in the well due to its anchoring engagement with the well casing. In such well installations, after the packer has been run into the well and set in position by means of the running tool 160, the running tool is disengaged from the packer mandrel and removed with the tubing string to the surface. The running tool is then disconnected from the lower end of the string of tubing and a connector tool 200 might be secured to the lower end of the string of tubing. The connector tool 200 includes an outer mandrel 201 having a top section 202 whose lower reduced end portions 203 is threaded on the upper end of its bottom section 204. The bottom mandrel section has an external annular flange 205 which provides an upwardly facing annular shoulder 206 which limits downward movement of a seal assembly 208:: disposed on the lower mandrel section. Upward movement of the seal assembly on the bottom mandrel section is limited by its engagement with the bottom annular shoulder 209 of the top mandrel section. The bottom mandrel section is provided with a pair of diametrically opposed J-slots 180a which are of the same configuration as the ]-slots 180 of the latch section 166 of the running tool 160. The elements of the bottom mandrel section defining the J-slots 180a have been provided with the same reference numerals, to which the subscript a has been added, as the corresponding elements of the J-slots 180 of the running tool 160.

It will be apparent that the connector tool may be lowered into the packer mandrel and be releasably secured thereto by means of the internal lugs 154 and the J-slots 180:: with the seal assembly 208 sealing between the outer mandrel 201 and the packer mandrel. Downward movement of the mandrel 201 in the packer mandrel is limited by the engagement of the annular downwardly facing shoulder 208a with the upwardly facing shoulder 177 of the packer mandrel. An internal annular seal assembly 210 is disposed in the top section 202 of the outer mandrel and is held against downward movement therein by an internal annular flange 211 thereof which provides the upwardly facing annular shoulder 212. Upward movement of the seal assembly is limited by a retainer ring 214 whose bottom end shoulder 215 engages the upper end of the seal assembly. The retainer ring has external annular threaded flange 216 which is secured in the enlarged threaded portion of the top mandrel section. The top mandrel section is provided above its threaded portion 217 with an annular stop shoulder 218 and with a pair of inwardly extending lugs 219. The connector tool includes a tubular connector member 220 which has a pair of diametrically opposed J-slots 222 in which the lugs 219 of the upper mandrel section are receivable to releasably connect the latch member to the mandrel. The lower threaded end portion of the string of tubing 161 is threaded in the upper end of the connector member and a tubular extension 1670:, which may be of relatively great length so that it will extend a considerable distance below the lower end of the packer mandrel, has its upper end portion threaded in the lower end portion of the connector member. The seal assembly 210 seals between the top mandrel section 202 and the tubular extension.

The J-slots 222 have horizontal portions 223 which extend in a counterclockwise direction as seen from above from their downwardly opening vertical portions 224. When downward movement of the connector tool is arrested by the engagement of the shoulder 203 of its outer mandrel with the shoulder 177 of the packer mandrel, counterclockwise rotation, as seen from above, is imparted to the string of tubing which first causes the tubular connector member 220 to rotate relative to the outer mandrel 201, unil the side vertical surfaces 226 of the connector member defining one side of the J-slots engage the facing sides of the lugs 219 of the outer mandrel. Further rotation of the connector member then causes the outer mandrel 201 to rotate therewith until the surfaces 186a of the outer mandrel defining the sides of the V-slots 180a engage the facing sides 187 of the lugs 154 of the packer mandrel. Upward movement then imparted to the string of tubing moves the string of tubing, the tubular connector 220 and the extension 167a upwardly relative to the outer mandrel which is now held against upward movement, since the lugs 154 of the packer mandrel now extend into the horizontal portions 182a of the J-slots 180a. The connector member may move upwardly relative to the outer mandrel since the lugs 219 are now in alignment with the vertical downwardly opening portions 224 of the J -slots 222 of the connector member. The string of tubing is raised a considerable distance relative to the outer mandrel 201 and the packer mandrel, for example, ten or twenty feet with the tubular extension 167a also extending a considerable distance, for example twenty or thirty feet, below the lower end of the packer mandrel. No appreciable longitudinal forces will now be imparted to the packer mandrel as the length of the string of tubing increases or decreases with temperature changes, the tubular extension 167a sliding through the outer mandrel 201 as the length of the string of tubing changes.

Sliding movement of the tubular extension relative to the outer mandrel will in time cause the seal assembly 210 to wear. When it is desired to replace the seal assembly, the string of tubing is lowered until the tubular connector member again moves downwardly into the outer mandrel and the vertical portions 224- of the J-slots receive the lugs 219 of the outer mandrel. A clockwise rotation then imparted to the string of tubing rotates the connector member 220 to move the horizontal sections 223 of the legs of the J-slots into alignment with the lugs 219 and, when the side surfaces 227 of the tubular member defining the outer ends of the J-slots engage the sides of the lugs 219, a clockwise rotation is imparted to the outer mandrel causing the vertical portions 181:: of its J-slots 180a to move into alignment with the internal lugs 154 of the packer mandrel. The tubing and the connector tool may then be removed upwardly to the surface, the seal assembly 210 replaced by a new seal assembly, the string of tubing and the connector tool lowered back to the packer mandrel, which is still anchored in the well casing, the outer mandrel again latched to the packer mandrel, and the connector member again released from the outer mandrel and moves thereon.

The connector tool 300 may be employed instead of the connector tool 200 to connect the string of tubing to the packer where appreciable movement of the string of tubing occurs relative to the packer mandrel due to the expansion and contraction of the string of tubing with temperature changes. The connector tool 300 includes an outer mandrel 301 having a top latch section 302, a middle seal section 303 and a bottom J-slot section 304. The bottom man-drel section is provided with an external annular flange 305 adjacent its bottom end provided with a pair of J-slots 18% which are of the same configuration as the J-slots 180 of the running tool 160 and, therefore, the elements of the bottom mandrel section defining the J-slots 18% have been provided with the same reference numerals, to which the subscript b has been added, as the corresponding elements of the running tool 160. An outer seal assembly 306 is disposed about the bottom mandrel section and its downward movement is limited by its engagement with the upwardly facing shoulder 306a of the external annular flange 305 of the bottom mandrel section. Upward movement of the seal assembly on the bottom mandrel section is limited by its engagement with the bottom annular shoulder 307 of the middle mandrel section which is threaded on the upper end portion of the bottom mandrel section.

The middle mandrel section 303 has an internal annular flange 308 whose top annular shoulder 309 limits downward movement of a seal assembly 310 mounted in the middle mandrel section. Upward movement of the seal assembly is limited by its engagement with the annular downwardly facing shoulder 312 of a retainer ring 314 whose external annular threaded flange 315 is threaded in the threaded intermediate portion 316 of the middle mandrel section.

The lower end of the top latch mandrel section 302 is threaded in the upper end of the middle section. The top mandrel section is provided with three circumferentially spaced I-slots 320 whose vertical portions 321 open upwardly and whose horizontal portions 322 extend in a clockwise direction, as seen from above, from the lower ends of the vertical portions.

The tubular connector member 330 of the connector tool 300 has a dependent enlarged skirt portion 332 which is telescoped over the top latch section 302 and held against downward movement relative thereto by a split snap ring 333. Inner portions of the split ring are received in an external annular recess 334 of the top mandrel section and its outer portions are received in the downwardly opening recess 335 of the skirt 332. The internal downwardly and outwardly extending shoulder 337 of the skirt engages the similarly inclined top shoulder 338 of the snap ring to hold the skirt against downward movement. The downwardly and outwardly inclined internal bottom shoulder 340 of the ring engages the annular shoulder 341 to the latch mandrel section 302 to limit the downward movement of the ring thereon.

The skirt is releasably held against upward movement from the top mandrel section by one or more shear pins 344 which extend through suitable apertures in the skirt into radially outwardly opening bores of the latch mandrel section.

The skirt 332 has three circumferentially spaced radially inwardly extending lugs 347 which are initially positioned in the vertical upwardly opening portions 321 of the J-slots 320. The extension 16712, which is of sufiicient length to extend through and below the packer mandrel, extends upwardly through the skirt 332 and is threadedly secured, as 350, to the connector member 330. The lower end of the string of tubing 161 is of course threaded in the upper end of the connector member.

The connector tool 300 is connectable to the packer 35, which is already set and anchored in the well casing, by connecting its connector member 330 to the lower end of the tubing and then lowering it into the well casing with its elements in the positions illustrated in the drawing. As the bottom mandrel section 304 moves into the upper end of the packer mandrel the internal lugs 154 of the packer mandrel are received in the downwardly opening vertical portions of the J-slots b and, when downward movement of the connector tool relative to the mandrel is arrested due to the engagement of the shoulder 352 of its bottom mandrel section 303 with the upwardly facing shoulder 177 of the packer mandrel, the tubing is rotated in a counterclockwise manner, as seen from above, to position the packer mandrel lugs 154 in the horizontal sections 1821) of the J-slots. Upward movement of the string of tubing and the connector tool then causes the shoulders 1841) defining the lower end of the horizontal portions 182!) of the J -slots 18% to engage and prevent further upward movement of the mandrel 301. An upward force then applied to the string of tubing, and therefore to the connector member 330 of the connector tool, causes the shear pin 344 to shear and, as the string of tubing continues to move upwardly, the lower end of the skirt 332 moves out of engagement with and above the snap ring. The snap ring, which is inherently of greater diameter than the external diameter of the top mandrel section, springs outwardly and drops downwardly on the top mandrel section 302 until its movement is arrested by the top shoulder 357 of the middle mandrel section 303. The string of tubing, the connector member 330 and the tubular extension 16712 are then raised upwardly relative to the outer tubular mandrel and the packer mandrel to the positions illustrated for example in FIGURE 18 of the drawing and the tubular extension can then move longitudinally relative to the outer mandrel 301 of the connector tool and the packer mandrel as the length of the string of tubing varies with temperature changes.

When it is desired to remove the connector tool from the packer, the string of tubing is again lowered until the downward movement of the string of tubing and the connector member 330 is arrested due to the engagement of the bottom shoulders 361 of the internal lugs 347 of the connector member with the upwardly facing shoulders 362 of the top mandrel section 302 which define the bottom ends of the J-slots. The string of tubing is then rotated in a counterclockwise manner, as seen from above, and when the sides 364 of the lugs 347 engage the vertical surfaces 365 of the top mandrel section defining the outer ends of the horizontal portions of the J-slots, further rotation in this direction of the string of tubing and the connector member now causes rotation of the outer mandrel 301 and the movement of its slots 18012 to positions wherein the vertical portions 18111 thereof are in alignment with the internal lugs 154 of the packer mandrel. The string of tubing and the connector tool may then be moved upwardly from the packer mandrel leaving the packer in place in the casing.

The connector tool 300 due to the provision of the shear pin 344 and the snap ring 333 prevents any acci dental rotation of the connector head 330 relative to the top latch section 302 during the lowering of the connector tool through the well casing and is preferred for this reason to the connector tool 200 wherein accidental rotation of the outer mandrel 201 relative to the connector member 220 could result in accidental disengagement of the outer mandrel from the connector member during the lowering of the connector tool through the well casing. The connector member 330 can be disengaged from the outer mandrel 301 only when the outer mandrel is latched to the packer mandrel since an upward force must be applied to the connector member to shear the shear pin 344. A downward force applied to the connector member will not cause the pin to shear since the connector member is held against downward movement relative to the top mandrel section by the snap ring 333.

Referring now particularly to FIGURE 20 of the drawing, the hydraulically operated packer 400 embodying the invention is similar to the packer 35 illustrated in FIGURES 1 and 2 and accordingly its elements have been provided with the same reference numerals, to which the subscript c has been added, as the corresponding elements of the well packer 35. The upper slip carrier 420 of the well packer 400 has a cylinder sleeve 402 telescoped over its reduced upper end portion 560 and is secured thereto by the screws 57c instead of the tubular internally threaded connector 55 of the well packer 35. The annular bottom end surface 404 of the top mandrel section 370 of the packer mandrel 360 is spaced upwardly from the top annular surface 405 of the upper slip carrier to provide an annular piston chamber 408 between the cylinder sleeve 402 and the main packer mandrel section 380.

An annular piston 410 is slidably disposed in the annular chamber and is provided with internal annular recesses in which are disposed O-rings 411 which seal between the piston and the main mandrel section 380 and with external annular recesses in which are disposed rings 412 which seal between the piston and the cylinder sleeve 402. The top packer mandrel section 37c is similarly provided with external annular recesses in which 0- rings 414 are disposed to seal between the top mandrel section and the cylinder sleeve and with an internal annular recess in which an O-ring 415 is disposed to seal between the two mandrel sections 370 and 380. The top mandrel section has a longitudinal passage 417 whose lower end opens to the top of the piston chamber and whose upper end opens to the interior of the top mandrel section at the upper end of its internal annular upwardly facing stop shoulder 1770.

The running and setting tool 160a is substantially similar to the running tool 160 illustrated in FIGURES 1 and 1A and, accordingly its elements have been provided with the same reference numerals, to which the subscript c has been added, as the corresponding elements of the running and setting tool 160. The running and setting tool 1600 has a seal assembly 1720 above its J-slots 1800 which seals between its middle latch section 1660 and the top packer mandrel section. The middle section 1660 has with one or more ports 420 which open to the J-slots 1800 and are in communication, through the annular passage 421 between the outer surface of the flange 1700 and the internal surface of the top packer mandrel section 370 with the upper end of the passage 417. A seal assembly 423 is mounted on the tubular extension 1670 and is held against upward movement thereon by the downwardly facing shoulder 427 of the middle latch section 1660 and against downward movement by a split retainer ring 428 whose inner portions are received in an external annular groove of the tubular extension. The seal assembly 423 seals between the tubular extension 1670 and the top packer mandrel section below its stop shoulder 1770 and below its lateral port 420.

A seat ring 430 is releasably secured to the tubular extension 167, by means of a shear pin 431. The seat ring is provided with an external annular recess above the shear pin 431 in which is disposed an O-ring 432 which seal between the seat ring and the internal surface of the tubular extension. The seat ring has a top seat surface 434 which is engageable by a plugball which may be dropped downwardly through the string of tubing 161 which is connectable to the top or connector section 1640 of the running tool.

The springs 740 which yieldably hold the upper slips 43c in their inner retracted positions do not extend radial ly outwardly of the upper slip carrier 420 as do the springs 74 of the packer 35, since their only function is to hold the slips 430 in their inner retracted positions. In use, the well packer 400 is connected to the running and setting tool 1600 in the manner illustrated in FIGURE 20 and when the packer is to be lowered into the well on the string of tubing 410 the packer mandrel will move downwardly on the running tool until the shoulders 1850 of its lugs 1540 are engaged by the upwardly facing shoulders 1840 of the latch section 1660 which define the lower ends of the horizontal portions of the J-slots 1800. The lower seal assembly 423 is now still in sealing engagement with the seal surface 424 below the stop shoulder 1770 of the packer mandrel and other elements of the packer are now in their inoperative positions on the mandrel illustrated in the drawing. The upper slip carrier is held in its upper position on the packer mandrel by the frictional engagement of the ring segments 600 with the slip carrier and the main mandrel section 380, the spring 610 urging the ring segments into such engagement. When the packer is at the desired location in the well casing, a plug ball 436 is dropped into the string of tubing at the surface and falls downwardly therethrough and through the running tool until it engages the seat surface 434 of the seat ring 430 thus closing the running tool below the lateral ports 420 thereof to downward flow therethrough. Fluid under pressure is then introduced into the string of tubing at the surface and the pressure of this fluid is communicated to the upwardly facing surfaces of the annular piston ring to exert a downward force on the piston and therefore on the upper slip carrier. The slip carrier is thus moved downwardly on the main mandrel section 380 toward the upper slip expander. The ring segments 60c of course permit such downward movement of the upper slip carrier. As the slip carrier and therefore the slips move downwardly on the main mandrel section 380, their inner cam surfaces 860 engage the cam surfaces 94c of the upper slip expander and are moved radially outwardly into anchoring or gripping engagement with the internal surfaces of the well casing. When downward movement of the slips is arrested, a further increase in the fluid pressure in the string of tubing causes the shear pin 431 to shear and the seat ring and the plug ball then are moved downwardly and out of the running too] through its tubular extension 1670. Upward movement of the string of tubing 161 will then cause the running tool and the packer mandrel to move upwardly relative to the upper slip carrier, the upper slips 43c and the expander assembly 440 and the packing element and the lower slips are moved to expanded sealing and anchoring engagement with the well casing in the same manner as previously described in connection with the well packer 35. Various well operations may then be performed or well fluids produced through the running tool and the string of tubing 161 while the string of tubing is preferably held in tension at the surface.

The running tool 1600 may be disconnected from the well packer by rotating the string of tubing to position the vertical portions 1810 of the J-slots 1800 in alignment with the internal lugs 1540 of the packer mandrel and then raising the tubing string upwardly. A connector tool, such as the connector tool 200 or 300 previously described, may then be connected to the string of tubing and to the well packer 400 in the same manner as previously described in connection with their installation into the well packer 35.

Referring now to FIGURE 21, the well packer 500 embodying the invention is similar to the well packer 35 and, accordingly, its elements have been provided with the same reference characters, to which the subscript d has been added, as the corresponding elements of the well packer 35. The well packer 500 is lowerable into a well casing by means of a suitable running and setting tool 501 such as the setting tool illustrated in Figure L-139 on page 491 of the 1964-65 Catalogue of Oil 'Field Equipment and Services, published by World Oil of Houston, Tex. The running and setting tool has an inner mandrel 502 which is telescopical into the upper end of the top section 37d of the packer mandrel 36d and is releasably secured thereto by means of shear pin 504 and a sleeve 505 which is telescopical over the top mandrel section and whose lower annular end surface 507 engages the top annular end surface 508 of a spacer sleeve 510 of the well packer. The upper end of the tubular extension 167d is threaded in the lower end of the inner mandrel 502 and engages the internal bosses 150d to latch the main mandrel section 38d against movement relative to the lower slip carrier 48d. The lower end of the spacer sleeve is telescoped over the reduced top end portion 56d of the upper slip carrier 44c and is secured thereto by means of the screw 57d which extends through a suitable aperture in the spacer sleeve into laterally outwardly opening bore of the upper slip carrier. The spacer sleeve 510 is employed in place of the internally threaded tubular connector 55 of the well packer 35. The running and setting tool has a powder charge which is ignited to operate the tool when it is desired to anchor and set the packer in the well tubing. When the ring and setting tool is operated, its sleeve 505 moves downwardly relative to its mandrel 502. The spacer sleeve is releasably secured to the top mandrel by means of one or more shear screws 512 when extend through suitable lateral apertures of the spacer sleeve into laterally outwardly opening bores of the top mandrel section.

The springs 74d which bias the upper slips 43d toward their retracted positions do not have middle portions which extend outwardly of the outer surface of the slip carrier. The lower end portions of the upper slips extend downwardly over the upper end portions of the expander fingers 91a of the expander 90d with their lower inner cam surfaces 86d engaging the upper portions of the cam surfaces 94d of the expander in order that a relatively short downward movement of the upper slip carrier and the upper slips relative to the expander 90d cause the slips to be moved outwardly into anchoring and gripping engagement with the internal surfaces of a well casing.

It will be apparent that the well packer 500 is lowered into the well casing by means of a cable or flexible line which has electrical conductors therein for delivering an electric current to the setting tool which is connected to the lower end of such flexible cable. When the well packer is at the desired location in the well casing, the setting tool is operated by transmitting an electric current thereto from the surface and its sleeve 505 moves downwardly relative to its mandrel 592. Such downward movement of the setting tool sleeve 505 causes the spacer sleeve 510, the slip carrier 44d and the slips 43d to move downwardly on the packer mandrel, the shear screw 512 shearing to permit such downward movement thereof. As the upper slip carrier and slips move downwardly, the upper slips are moved outwardly against the resistance of the springs 740! due to their engagement in the expander 900! until the outward movement of the slips is arrested when the slips are in gripping or anchoring engagement with the well casing. An upward pull then imparted to the flexible cable causes the packer mandrel to move upwardly and the packing element 45d and the lower slips 47d are expanded into sealing and anchoring engagement with the well casing. When further upward movement of the lower slips is arrested due to their engagement with the well casing a continued upward pull exerted on the setting tool by means of the flexible cable causes the shear pin 504 to shear whereupon the setting tool and its extension 167d are removed upwardly from the well casing. A string of tubing having a connector tool, such as the connector tool 200 or 300, secured to its lower end is then lowered into the well casing and connected by such connector tool to the well packer. The well packer 500 may of course be removed in the same manner and by use of the same tool as the well packer 35.

Referring now particularly to FIGURE 22 of the drawing, the bridge plug 600 has the same anchoring and sealing means as the well packer and, accordingly, the elements of the bridge plug 600 have been provided with the same reference numerals, to which the subscript e has been added, as the corresponding elements of the well packer 35. The upper slip carrier 42e is releasably se cured to the top mandrel section 37a by a spacer sleeve 55s, the lower end of the spacer sleeve 55e extending over the reduced top portion 56e of the upper slip expander and being secured thereto by the screw 57a and its upper portion extending over the lower portion of the top packer mandrel section 37c and being releasably secured thereto by a shear screw 601 which extends through a suitable lateral aperture of the spacer sleeve into a laterally outwardly opening bore of the top mandrel section. The bridge plug is positionable in the well and set therein by a means for a setting tool 602 lowerable into the well on a flexible cable which includes a pair of electrical conductors such as a setting tool illustrated in Figure L-139 on page 491 of the 1964-65 Composite Catalogue of Oil Field Services and Equipment, published by World Oil, Houston, Tex. Such setting tool includes an inner mandrel 603 whose lower portion is adapted to telescope the upper end of the packer mandrel section 37e and be releasably secured thereto by shear screws 604 and an outer sleeve 605 whose bottom annular end shoulder or surface 607 engages the top annular end surface or shoulder 608 of the spacer sleeve 55a. The setting tool, when operated by an electric current transmitted thereto through the conductors of the cable by which it is lowered into the well, causes the sleeve 605 to move downwardly relative to the inner mandrel. The main mandrel section 38c, which is threaded in the lower end portion of the top mandrel section 37e, has disposed thereon an upper slip carrier 42e, upper slips 432, an expander assembly Me, a packing element 45s, a lower slip expander 46c, lower slips 47c, and a lower slip carrier 48c which are identical in structure, function and mode of operation as the corresponding elements of the well packer 35.

The bridge plug has an inner tubular latch mandrel 610 mounted therein on whose lower end portion is threaded a tubular extension 167e which extends downwardly below the lower end of the main mandrel section 38e and engages the inner bosses e of the resilient fingers 149 to prevent inward movement thereof and thus hold the mandrel against upward movement relative to the lower slip carrier 48a. The latch mandrel 610 is releasably held in the lower position illustrated in FIGURE 22A in the mandrel 36e by a plurality of latch balls 612 movably disposed in the circumferentially spaced lateral apertures 613 of the latch mandrel. The outer portions of the latch balls extend into an annular internal recess 614 of the top mandrel section 37:2. The latch balls are held against inward movement by a tubular valve member 616 when it is held in its lower position in the latch mandrel illustrated in FIGURE 22A by a lower set of circumferentially spaced shear pins 618 whose outer end portions are secured in the lateral apertures 619 of the latch mandrel and above an annular upwardly facing shoulder 620 of the valve member provided by a reduction in the external diameter of the upper portion 622 of the valve member. An upper set of circumferentially spaced shear pins 624 are secured in the lateral aperture 625 of the latch mandrel and extend inwardly to positions to engage the shoulder 620 when the valve member is moved upwardly in the latch mandrel as will be explained herebelow. Upward movement of the valve member after the lower and upper sets of shear pins have been sheared is limited by the downwardly facing shoulder 628 provided by the top internal annular flange 629 of the latch mandrel. The valve member has an external annular recess 631 into which the inner portions of the latch balls are movable when a valve member is moved upwardly to an intermediate position wherein its further upward movement is limited by the shear pins 624.

The valve member is provided with a pair of external annular recesses in which are disposed the O-rings 633 and 634 which seal between the valve member and the latch mandrel above and below the one or more lateral ports 635 of the latch mandrel. The lateral ports communicate with the central bore or passage 636 of the latch mandrel and the annular passage 637 between the main mandrel section 38: and the latch mandrel 610 and its tubular extension 167e. The valve member has a fishing 17 neck 638 threaded thereon which has an external annular flange 640 providing a downwardly and outwardly extending annular shoulder 641 which is engageable by a suitable fishing tool. The valve member and the fishing neck have aligned longitudinal passages 643 and 644, respectively.

The lower end of the latch mandrel is closed by a plug member 646 whose lower external annular flange 647 is disposed in an annular internal recess 648 whose upper end is defined by the downwardly facing annular end surface or shoulder 649 of the latch mandrel and whose bottom is defined by the upwardly facing annular shoulder 650 of the tubular extension 167e. The plug member has an external annular recess in which an O-ring 652 is disposed which seals between the plug member and the internal seal surface 654 of the latch mandrel.

In use, the bridge plug is connected to the inner mandrel and sleeves 603 and 605 of the setting tool 602 and the elements of the bridge plug are in the positions illustrated in FIGURES 22A and 22B wherein the latch mandrel is held against movement relative to the mandrel 362 by the latch balls 612 and the valve member is held against upward movement relative to the latch mandrel by the lower set of shear pins 618. Downward movement of the valve member relative to the latch mandrel is limited by the engagement of the bottom end surface or shoulder 656 of the fishing neck with the top end surface or shoulder 657 of the latch mandrel. When the bridge plug has been lowered to the location at which it is desired that it be anchored and set in the well casing, the setting tool is operated by an electric current transmitted thereto from the surface through the electric conductors of the cable by means of which the setting tool and the bridge plug are lowered into the well. When the setting tool is operated, its sleeve 605 is moved downwardly relative to its mandrel 603 and since the bottom shoulder 607 of the sleeve 605 engages the top end surface of the spacer sleeve 55c, the spacer sleeve 55:: and also the upper slip carrier 42e are moved downwardly while the setting tool mandrel 603 holds the bridge plug mandrel 36e against downward movement. Such downward movement of the upper slip carrier causes the upper slips 43e to move downwardly over the upper end of the expander 90c and the slips are moved outwardly into expanded gripping and anchoring engagement with the well casing. The setting tool is then moved upwardly to sequentially cause the packing element 45c to be expanded into sealing engagement with the well casing and the lower slips 47a to be moved outwardly into anchoring engagement with the well casing in the manner previously described in connection with the well packer 35. Upward movement of the lower slip carrier 48e and the lower slips 472 is arrested when the lower slips are in anchored engagement with the well casing and cannot move farther outwardly. An upward force then exerted on the setting tool by means of the flexible cable causes the shear pins 604 to shear and the setting tool is thus freed from the bridge plug mandrel 36e and may be moved upwardly for removal from the casing. The bridge plug then is in anchored and sealing position in the well casing closing the well casing to flow therethrough. The mandrel 36c is now locked against movement in the well casing since the fingers 14912 of the main mandrel section 382 are held against inward movement by the latch extension 167e.

When it is desired to remove the bridge plug from the well casing, a suitable fishing tool such as the Type R Pulling Tool illustrated on page 3746 of the Composite Catalogue of Oil Field Equipment and Services is lowered into the well by means of a flexible line and the usual set of flexible line tools. Such pulling tool has means which telescope over the fishing neck and engage the bottom shoulder 641 of the fishing neck whereby an upward pull then exerted on the fishing neck causes the fishing neck and valve member to move upwardly, the lower set of shear pins 618 shearing to permit such movement. When the upward movement of the valve member is arrested due to the engagement of the shoulders 620 thereof with the upper set of shear pins 624, the valve member is in an intermediate position in the latch mandrel which permits the pressure across the bridge plug to equalize. In the case of an upwardly acting pressure differential thereacross, the pressure is equalized by the flow of fluid upwardly through the passage 637, the lateral ports 635, the latch mandrel, and the passages 643 and 644 of the valve member and the fishing neck. If the pressure above the bridge plug is greater than the pressure below the bridge plug, the fluid will flow in the reverse direction. The latch balls 612 are still held in their outer latching position and in engagement with the latch recess 614 of the top mandrel section 37e preventing upward or downward movement of the latch mandrel when the valve member is in this intermediate position.

Any small inner portions of the shear pins 618 which have been sheared and which are between the valve member and the latch mandrel will move between the upper set of pins 624 and will not prevent the engagement of the shoulder 220 with the upper set of pins. In the event that any such portion should be lodged between the shoulder 221 and one of the pins 622, suflicient upward movement of the valve member will have occurred to position the O-ring 634 above the lateral port 635 so that fluid may flow through the lateral port between the passage of the latch mandrel and the passage 637. Further upward force then imparted to the valve member causes the upper set of shear pins 624 to shear and, as the valve member is moved upwardly, its external annular recess 631 moves into alignment with the latch balls. The external recess 631 is of suflicient width that even if portions of the shear pins are trapped 'between the shoulders 620 and 628 of the valve member and the latch mandrel, respectively, thus limiting upward movement of the valve member relative to the latch mandrel, the recess 631 will still be in alignment with the latch balls so that the latch balls may move outwardly thereinto. A further upward force then exerted on the fishing neck and the valve member will also cause an upward force to be imparted to the latch mandrel. The camming engagement between the latch balls and the upwardly and inwardly inclined shoulder of the top mandrel section 37e defining the upper end of the annular latch recess 614 now moves the latch balls inwardly into the recess 631 thus freeing the latch mandrel for upward movement in the mandrel 36c. Continued upward force then exerted on the fishing neck causes the latch mandrel and the tubular extension 167e to move upwardly in the mandrel 36e until the top end shoulder 670 of the tubular extension 167e engages the downwardly facing annular shoulder 671 of the top mandrel section 370. At this time the lower end of the tubing extension 167e is disposed above the upper ends of the fingers 14% of the main mandrel section 38e so that a further upward force then imparted to the fishing neck, and therefore to the valve member, the latch mandrel, and the tubular extension, will cause upward movement of the mandrel 36e relative to the upper and lower slips and the sealing element. As upward movement of the mandrel 36a is continued, the wedge ring 1962 is moved upwardly to free the fingers of the expander '90:: for inward movement to free the upper slips for movement to their retracted positions, the upper slips are moved upwardly relative to the expander, the sealing element 45:: moves to its retracted positions and the lower expander is moved upwardly relative to the lower slips. The bridge plug is thus moved out of anchored and sealing position in the well casing and can now be removed from the well.

It will now be seen that several forms of the well tool embodying the invention have been illustrated and described, each of which 'has a mandrel having upper and lower anchoring means and a sealing means disposed therebetween, wherein the mandrel is anchored in a flow conductor, such as a well casing, by causing relative longitudinal movement between the upper set of slips and their expander means and then subsequent upward movement of the mandrel relative thereto.

It will further be seen that the mandrel is releasably secured against upward movement relative to the lower slip carrier by an extension of a well tool positioned in the mandrel and that the anchoring and sealing means are movable from their anchoring and sealing positions upon continuous upward movement of the mandrel relative thereto when the mandrel is released for upward movement relative to the lower slip carrier by the upward movement of such well tool in the mandrel.

It will further be seen that the mandrel has an upper stop means, such as the stop ring 1 which is engageable with the expander means of the upper slips for freeing the expander means to be freed for movement toward retracted positions permitting movement of the upper slips to their inner retracted positions and out of anchoring engagement with the flow conductor and then engaging the upper slips to move the slips and upper slip carrier upwardly therewith, and with a lower stop means, such as the ring 138 for thereafter engaging the lower slip expander to cause it to move relative to the lower slips to permit the lower slips to move to their retracted positions.

It will further be apparent that if the well tool is in the form of a well packer through which an extension of the string of tubing is to extend, the mandrel is provided with latch means, such as the lugs 154, engageable with a latch means of a tool, such as the running tool 160 or the connector tools 160 and 330, connected to the string of tubing, which permits such tool to position such extension in the packer mandrel and permits longitudinal movement of such extension in the packer mandrel.

It will further be seen that each of running and connector tools has an inner mandrel positionable in the mandrel of the packer and provided with an external seal assembly for sealing between such i'nner mandrel and the packer mandrel and with inner seal means for sealing between such inner mandrel and the extension which is movable longitudinally therein.

It will further be seen that the connector tools are provided with latch means for releasably engaging such inner mandrel whereby the inner mandrel may be connected to the packer mandrel and may be removed from the packer mandrel by such connector tool.

The foregoing description of the invention is explanatory only, and changes in the details of the construction illustrated may be made by those skilled in the art, within the scope of the appended claims, without departing from the spirit of the invention.

What is claimed and desired to be secured by Letters Patent is:

1. A well tool positionable in a flow conductor including: a tubular mandrel; an upper slip carrier on said mandrel; upper slip means carried by said upper slip carrier and movable between inner retracted positions and outer expanded positions relative to said mandrel; upper expander means on said mandrel movable between an operative position wherein said upper expander means is adapted to hold said upper slip means in expanded position and an inoperative position wherein said upper slip expander permits said upper slip means to move inwardly toward said retracted position; holding means releasably holding said upper expander means in said operative position; a lower slip carrier on said mandrel, said mandrel and said lower slip carrier having coengageable means releasably holding said lower slip carrier against movement on said mandrel; lower slip means carried by said lower slip carrier and extending upwardly thereof; said lower slip means being movable between inner retracted position and outer expanded position relative to said mandrel; lower expander means on said mandrel engageable with said lower slip means for moving said lower slip means to expanded position upon longitudinal movement therebetween; sealing means disposed on said mandrel between said upper and lower expander means and movable outwardly to expanded sealing position upon movement of said lower expander means toward said upper expander means; first stop means carried by said mandrel engageable with said holding means upon upward movement of said mandrel relative to said upper expander means, for moving said holding means from said operative position to said inoperative position, said upper slip means having means engageable with said holding means upon upward movement of said holding means relative thereto for causing upward movement of said upper slip means relative to said upper expander upon movement of said holding means from position holding said upper expander means in said operative position; and second stop means on said mandrel engageable with said lower expander means for moving said lower expander means relative to said lower slip means to move said lower slip means to its retracted position upon upward movement of said mandrel relative to said lower slip carrier and said lower expander means after said upper slips have been moved to retracted positions.

2. In combination with the well tool of claim 1: a tool releasably securable to said mandrel and having an extension extending downwardly through said mandrel, said extension being engageable with said coengageable means of said mandrel to prevent release of said mandrel for movement relative to said lower slip car-rier.

3. In combination with the well tool of claim 1: a tool having a tubular extension extendable downwardly through said mandrel, said tool and said mandrel having coengageable means releasable upon rotational movement of said tool relative to said mandrel to permit longitudinal movement of said tool relative to said mandrel, said extension being engageable with said coengageable means of said mandrel to prevent release of said mandrel for movement relative to said lower slip carrier.

4. The well too] of claim 1 including: a tubular latch member disposed in said tubular mandrel and movable therein between upper and lower positions, said latch member having dependent means engaged with said coengageable means of said mandrel to hold said mandrel against upward movement relative to said lower slip carrier when said latch member is in said lower position, said latch member having passage means communicating with the exterior of said mandrel below said sealing means; and a tubular valve member in said latch member movable therein between a lower closed position wherein it closes said passage means and an upper position wherein said passage means is open; and latch means carried by said latch member engageable with said tubular mandrel for holding said latch member against movement from said lower position when said valve member is in said closed position.

5. In combination with the well tool of claim 1: a tool connectable to an inner flow conductor for establishing communication between the lower end of the inner flow conductor and the flow conductor in which the well tool is positioned below the well tool, said tool including a connector member securable to the inner flow conductor; an outer mandrel releasably secured to said connector memher and telescopical into said tubular mandrel of said well tool, said tubular mandrel and said outer mandrel having coengageable means for releasably securing said outer mandrel to said tubular mandrel, said connector member having a tubular extension extending through said outer mandrel and said tubular mandrel and engageable with said coengageable means of said tubular mandrel to pre* vent release of said tubular mandrel for movement relative to said lower slip carrier, said outer mandrel having seal means for sealing between said extension and said tubular mandrel.

6. The combination of claim 5, wherein said connector member is releasable from said outer mandrel for movement to position above said outer mandrel whereby said tubular extension is free to move longitudinally in said outer mandrel and said tubular mandrel.

7. The well tool of claim 1 including: a tubular latch member disposed in said tubular mandrel and movable therein between upper and lower positions, said latch member having dependent means engaged within said co engageable means of said mandrel to hold said mandrel against upward movement relative to said lower slip carrier when said latch member is in said lower position, said latch member having passage means communicating with the exterior of said mandrel below said seal means; means closing said tubular latch member below said passage means; a valve member in said latch member movable therein between a lower position, an intermediate position and an upper position, said valve member closing said passage means when in said lower position; latch means for releasably holding said latch member in said lower position when said valve means is in said lower position, said latch member and said valve means having releasable means for permitting movement of said latch means upon a first upward force being imparted to said valve member and second releasable means for releasably holding said valve member in said intermediate position and releasable upon a second upward force being imparted to said valve member to permit movement of said valve member to said upper position, said latch means releasing said latch member for movement relative to said tubular mandrel when said valve member is in said upper position.

8. The well tool of claim 7 wherein said latch means include movable means movably carried by said latch member and an internal latch recess of said tubular mandrel, said movable means extending into said latch recess when said valve member is in said lowermost position and being held therein by said valve member, said movable means being movable out of said latch recess to release said tubular member for upward movement relative to said tubular mandrel when said valve member is in said upper position.

9. A well tool positionable in a flow conductor and including: a tubular mandrel; an upper slip carrier on said mandrel; first means releasably holding said upper slip carrier in an upper position on said mandrel; upper slip means carried by said upper slip carrier and movable between inner retracted positions and outer expanded positions relative to said mandrel; upper expander means on said mandrel engageable with said upper slips to move said upper slip means to expanded position upon upward movement of said expander means relative to said upper slip means, said upper expander means being movable between an operative position wherein said upper expander means is adapted to hold said upper slip means in expanded position and an inoperative position wherein said upper slip expander means permits said upper slip means to move inwardly towards said retracted position; second holding means releasably holding said upper expander means in said operative position; a lower slip carrier on said mandrel, said mandrel and said lower slip carrier having coengageable means releasably holding said lower slip carrier against movement on said mandrel; lower slip means carried by said lower slip carrier and extending upwardly thereof, said lower slip means being movable between inner retracted positions and outer expanded positions relative to said mandrel; lower expander means on said mandrel engageable with said lower slip means for moving said lower slip means to expanded position upon upward movement of said lower slip carrier and said lower slip means relative to said lower expander means; third means releasably holding said lower expander means in an upper position on said mandrel; seal means on said mandrel between said upper and lower expander means and movable to expanded sealing position upon movement of said lower expander means toward said upper expander means; first stop means carried by said mandrel engageable with said second holding means upon upward movement of said mandrel relative to said second holding means for moving said second holding means from said operative position to said inoperative position, said upper slip means having means engageable with said second holding means upon upward movement of said second holding means relative thereto for causing upward movement of said upper slip means relative to said upper expander means upon upward movement of said second holding means from position holding said upper expander means in said operative position; and second stop means on said mandrel engageable with said lower expander means for moving said lower expander means relative to said lower slip means to move said lower slip means to retracted position upon upward movement of said mandrel relative to said lower slip carrier and said lower expander means after said upper slips have been moved to retracted positions.

10. The well tool of claim 9; and means operatively associated with said upper slip carrier and said mandrel for preventing upward movement of said slip carrier on said mandrel.

11. The well tool of claim 9 wherein said upper slip carrier is releasable for longitudinal movement relative to said mandrel upon rotation of said mandrel relative to said upper slip carrier, said upper slip carrier having means engageable with a well flow conductor in which said well tool is positionable to resist rotation of said slip carrier in said flow conductor.

12. In combination with the well tool of claim 9; a tool releasably securable to said tubular mandrel and having an extension extending downwardly through said man-drel, said extension being engageable with said coengageable means of said mandrel to prevent release of said mandrel for movement relative to said lower slip carrier.

13. In combination with the well tool of claim 12, wherein said upper slip carrier is releasable for longitudinal movement relative to said mandrel upon rotation of said mandrel relative to said upper slip carrier, said upper slip carrier having means engageable with a Well fiow conductor in which said well tool is positionable to resist rotation of said slip carrier in said flow conductor.

14. The well tool of claim 9, wherein said tubular mandrel and said upper slip carrier have means providing a piston chamber; a piston movably disposed in said piston chamber, said tubular mandrel having passage means for introducing pressure to said piston chamber from the interior of said mandrel to cause said piston to move said upper slip carrier downwardly on said mandrel.

15. In combination with the well tool of claim 14: a tool having a tubular extension cxtendable downwardly through said tubular mandrel, said tool and said tubular mandrel having coengageable means releasable upon predetermined rotational movement of said tool relative to said tubular mandrel to permit longitudinal movement of said tool relative to said mandrel, said extension being engageable with said coengageable means of said mandrel to prevent said coengageable means from releasing said tubular mandrel for movement relative to said lower slip carrier, said tool having a passage communicating gith the interior of said tubular mandrel and said cham- 16. In combination with the well tool of claim 14: a tool releasably connectable to an inner flow conductor for establishing communication between the lower end of the inner flow conductor and the flow conductor in which the tool is positioned below the well tool, said tool including: a connector member releasably secured to said tubular mandrel and having passage means to provide communication between the inner flow conductor and said piston chamber, said tubular mandrel and said connector member having coengageable means for releasably securing said connector member to said tubular mandrel, said connector member having a tubular extension extending through said mandrel of said tubular mandrel and engageable with said coengageable means of said 23 tubular extension having seat means engageable by a plug for closing the lower end of said tubular extension whereby fluid pressure may be raised in said chamber to cause said piston to move said upper slip carrier downwardly on said mandrel.

17. A well installation including: a well packer having a tubular mandrel positionable in a flow conductor of the well and provided with anchoring and sealing means for anchoring said tubular mandrel in the well flow conductor and for sealing therebetween; an inner flow conductor having a lower extension extending slidably through said mandrel of the well packer for accomodating changes in length of said inner flow conductor, said extension conducting fluids through said mandrel between the well flow conductor below the well packer and the inner fiow conductor, said mandrel and said anchoring and sealing means having coengageable means for holding said mandrel against movement to a position holding said anchoring and sealing means in anchoring and sealing engagement with the well How conductor, said tubular extension engaging said coengageable means of said mandrel to hold said coengageable means in operative position preventing movement of said mandrel from said position.

18. A well installation including: a well packer having a tubular mandrel positionable in a flow conductor of the well and provided with anchoring and sealing means for anchoring said tubular mandrel in the well flow conductor and for sealing therebetween, said anchoring and sealing means being moved to anchoring and sealing position upon upward movement of said mandrel in said well flow conductor relative to said anchoring and sealing means to a first position relative to said anchoring and sealing means; an inner flow conductor having a lower extension extending through said mandrel of the well packer for conducting fluids through said packer and between the well flow conductor below the packer and the inner flow conductor; said mandrel and, said anchoring and sealing means having coengageable means for holding said mandrel against upward movement relative to said anchoring and sealing means from said first position, said anchoring and sealing means being released for movement to retracted positions out of anchoring and sealing engagement with the well flow conductor upon upward movement of said mandrel relative thereto from said first position, said tubular extension engaging said coengageable means of said mandrel to hold said mandrel against movement from said first position; said coengageable means releasing said mandrel for upward movement from said first position upon an upward force being imparted to said mandrel after said extension has been released from said mandrel.

19. The well installation of claim 18, wherein an outer tubular member is telescoped in said upper end of said tubular mandrel, said tubular mandrel and said tubular member having first releasable means for releasably securing said tubular member in said tubular mandrel, said tubular member having seal means for sealing between said tubular extension and said tubular mandrel, said inner flow conductor having a connector member, said connector member and said tubular memher having second releasable means for releasably connecting said connector member to said tubular member whereby said tubular member may be moved through the well flow conductor and into said tubular mandrel by means of said connector member and releasably secured therein and the connector member may then be released from said tubular member to permit movement of the connector member and extension upwardly therefrom whereby longitudinal changes in length of said inner flow conductor may be accommodated by sliding movement of said tubular extension in said tubular member in said mandrel.

20. The Well installation of claim 19, wherein said first releasable means includes external downwardly opening J-slot means on said tubular member and inwardly projecting lug means on said tubular mandrel, said lug means being receivable in said J-slot means upon rotation of said tubular member in one predetermined direction relative to said tubular mandrel, said second releasable means including upwardly opening J- slot means on said tubular member and inwardly projecting means on said connector member, said lugs being movable into said J-slot means on downward and then rotational movement of said connector member relative to said tubular member in second direction opposite said one direction.

21. A connector tool for use with a well tool having a tubular mandrel provided with internal lug means, said connector tool including: a tubular connector member having a tubular extension telescopical through the mandrel to extend a substantial distance therebelow; a tubular member having an upper portion telescopical with said connector member and a lower portion telescopical in the tubular mandrel and about said extension, said tubular member having seal means for sealing between the tubular member and the mandrel and said extension, said tubular member having first J-slot means engageable with the lug means of the mandrel upon downward and rotational movement of said tubular member in the mandrel for releasably securing said tubular member in the mandrel, one of said connector members and said tubular member having second J-slot means and the other of said connector members and said tubular members having second lug means receivable in said second J-slot upon downward and rotational movement of said connector member relative to said tubular member.

22. The connector tool of claim 21 wherein said tubular member is moved to position freed for upward removal from the mandrel upon rotation thereof relative to the mandrel in one direction and said connector member is moved to position freed for upward removal from said tubular member upon rotation of said connector member in a direction opposite said one direction.

23. The connector tool of claim 21, wherein said connector member is initially in a first upper position telescoped over said tubular member, said tool including first means initially releasably holding said connector member against upward movement relative to said tubular member and second means coengageable with said tubular and connector members initially holding said connector member in said upper position against downward movement relative to said tubular member, said second means being rendered inoperative after said connector member moves upwardly from said upper position, said connector member being provided with said second lug means and said tubular member being provided with said second J-slot means, said second lug means being receivable in said second J-slot means after said connector member is moved upwardly from said first position and then downwardly and rotationally relative to said tubular member.

24. The connector tool of claim 23, wherein said first means are shearable upon an upward force being imparted to said connector member and wherein said second means includes a resilient member engageable with facing shoulders of said connector and tubular members and held in engagement therewith by said connector member when said connector member is in said first upper position. I

25. A well tool including: an elongate tubular mandrel; longitudinally spaced anchoring means on said mandrel; deformable seal means on said mandrel between said anchoring means; said anchoring means being movable to anchoring position and said seal means deformed to sealing position upon longitudinal movement of said mandrel in one direction with respect to one of said anchoring means and said seal means; coengageable means on each of said anchoring means and said mandrel for releasably holding said mandrel against longitudinal movement with respect to said anchoring means; and a member releasably connected with said mandrel and disposed in engagement with one of said coengageable means for holding said coengageable means in position holding said mandrel against longitudinal movement with respect to the anchoring means with which said coengageable means is engaged, whereby the well too] is locked in anchored sealing position; said member being movable from engagement with said one coengageable means to permit said mandrel to be moved longitudinally with respect to each anchoring means and said seal means to release said Well tool from anchored sealing position.

26. A Well packer of the character set forth in claim 25 having its tubular mandrel provided with internal lug means, and a connector tool adapted for releasably connecting a well flow conductor to said packer in sealed flow conducting communication with the tubular mandrel of said packer and including: a tubular member connectable to the lower end of said well flow conductor and having a lower end portion extending telescopically through the tubular mandrel, said member having downwardly opening J-slot means for receiving the lug means of the tubular mandrel and engageable therewith to prevent upward movement of the member relative to the mandrel upon downward telescopical movement of the member in the tubular mandrel and rotation of the tubular member in a one predetermined direction relative to said tubular mandrel.

References Cited UNITED STATES PATENTS 3,109,490 11/1963 Baker 166-123 X 3,119,450 1/1964 Evans 166-119 3,244,233 4/1966 Vill-alon 166-123 3,256,437 6/1966 Muse 166-139 3,356,142 12/1967 Crow et a1. 166-134 2,714,931 8/1955 Bouvier 166-134 X 2,906,344 9/1959 Clark 166-140 2,929,453 3/1960 Conrad 166-217 X 2,970,649 2/ 1961 Brown 16 6-134 X 2,998,073 8/1961 Clark et a1 166-1'34 3,131,764 5/1964 Muse et a1. 166-123 3,265,131 8/1966 Ehlert 166-120 3,283,821 11/ 1966 Brown 166-134 DAVID H. BROWN, Primary Examiner. 

